U.S. patent number 11,306,575 [Application Number 16/520,598] was granted by the patent office on 2022-04-19 for releasably connectible downhole flow diverter for separating gases from liquids.
This patent grant is currently assigned to Schlumberger Canada Limited. The grantee listed for this patent is Schlumberger Canada Limited. Invention is credited to Shawn Deugo, Rob Hari, Tim Keith, Dave Kimery, Jeffrey Charles Saponja.
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United States Patent |
11,306,575 |
Saponja , et al. |
April 19, 2022 |
Releasably connectible downhole flow diverter for separating gases
from liquids
Abstract
A reservoir production assembly for disposition within a
wellbore that extends into a subterranean formation is disclosed.
The reservoir production assembly includes a flow diverter
including a cavity. The flow diverter defines a reservoir fluid
receiver, a reservoir fluid-conducting space, a reservoir fluid
discharge communicator, a gas-depleted reservoir fluid receiver, a
gas-depleted reservoir fluid-conducting space, and a gas-depleted
reservoir fluid discharge communicator. The reservoir production
assembly includes a downhole-disposed reservoir fluid-supplying
conductor for receiving the reservoir fluid from a downhole
wellbore space and conducting the received reservoir fluid to the
reservoir fluid receiver, and an on-off tool effecting releasable
coupling of the reservoir fluid receiver of the flow diverter to
the downhole-disposed reservoir fluid-supplying conductor with
effect that fluid coupling of the flow diverter to the
downhole-disposed reservoir fluid-supplying conductor is effected.
At least a portion of the on-off tool is disposed within the cavity
of the flow diverter.
Inventors: |
Saponja; Jeffrey Charles
(Calgary, CA), Hari; Rob (Calgary, CA),
Kimery; Dave (Calgary, CA), Keith; Tim (Calgary,
CA), Deugo; Shawn (Calgary, CA) |
Applicant: |
Name |
City |
State |
Country |
Type |
Schlumberger Canada Limited |
Calgary |
N/A |
CA |
|
|
Assignee: |
Schlumberger Canada Limited
(Calgary, CA)
|
Family
ID: |
69178039 |
Appl.
No.: |
16/520,598 |
Filed: |
July 24, 2019 |
Prior Publication Data
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|
|
Document
Identifier |
Publication Date |
|
US 20200032637 A1 |
Jan 30, 2020 |
|
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
Issue Date |
|
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62703386 |
Jul 25, 2018 |
|
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Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B
43/121 (20130101); E21B 43/38 (20130101); E21B
43/12 (20130101); E21B 17/1078 (20130101) |
Current International
Class: |
E21B
43/38 (20060101); E21B 43/12 (20060101); E21B
17/10 (20060101) |
References Cited
[Referenced By]
U.S. Patent Documents
Foreign Patent Documents
Primary Examiner: Wright; Giovanna
Attorney, Agent or Firm: Dae; Michael
Parent Case Text
CROSS-REFERENCE TO RELATED APPLICATIONS
This application is claims priority from U.S. Application No.
62/703,386, filed on Jul. 25, 2018. The entire contents of this
priority application is incorporated herein by reference.
Claims
What is claimed is:
1. A reservoir production assembly for disposition within a
wellbore that extends into a subterranean formation and is lined
with a wellbore string, wherein the reservoir production assembly
comprises: a flow diverter body including a cavity; wherein: the
flow diverter body defines a reservoir fluid receiver, a reservoir
fluid-conducting space, and a reservoir fluid discharge
communicator, wherein the reservoir fluid receiver, the reservoir
fluid-conducting space, and the reservoir fluid discharge
communicator are co-operatively configured such that, while
reservoir fluid is being received by the reservoir fluid receiver,
the reservoir fluid is conducted to the reservoir fluid discharge
communicator via the reservoir fluid-conducting space, and
discharged into a reservoir fluid separation space of the wellbore
from the reservoir fluid discharge communicator with effect that
gaseous material is separated from the discharged reservoir fluid
such that a gaseous depleted reservoir fluid is obtained; the flow
diverter body also defines a gas-depleted reservoir fluid receiver,
a gas-depleted reservoir fluid-conducting space, and a gas-depleted
reservoir fluid discharge communicator, wherein the gas-depleted
reservoir fluid receiver, the gas-depleted reservoir
fluid-conducting space, and the gas-depleted reservoir fluid
discharge communicator are co-operatively configured such that,
while reservoir fluid is being received by the gas-depleted
reservoir fluid receiver, the gas-depleted reservoir fluid is
conducted to the gas-depleted reservoir fluid discharge
communicator via the gas-depleted reservoir fluid-conducting space,
and discharged from the gas-depleted reservoir fluid discharge
communicator for supplying to a pump; and the flow diverter is
orientable such that, while the reservoir fluid is being discharged
into the reservoir fluid separation space from the reservoir fluid
discharge communicator such that the gaseous depleted reservoir
fluid is obtained in response to the separation of the gaseous
material from the discharged reservoir fluid, the gas-depleted
reservoir fluid receiver is disposed relative to the reservoir
fluid discharge communicator for receiving the gas-depleted
reservoir fluid obtained from the separation; a downhole-disposed
reservoir fluid-supplying conductor for receiving the reservoir
fluid from a downhole wellbore space and conducting the received
reservoir fluid to the reservoir fluid receiver; and an on-off tool
effecting releasable coupling of the reservoir fluid receiver of
the flow diverter to the downhole-disposed reservoir
fluid-supplying conductor with effect that fluid coupling of the
flow diverter to the downhole-disposed reservoir fluid-supplying
conductor is effected; wherein at least a portion of the on-off
tool is disposed within the cavity.
2. The reservoir fluid production assembly as claimed in claim 1,
further comprising: a sealed interface effector for becoming
disposed in sealing engagement, or substantially sealing
engagement, with the wellbore string for establishing a sealed
interface; wherein: the sealed interface effector and the flow
diverter body are co-operatively configured such that, while: (i)
the sealed interface effector is disposed in sealing engagement, or
substantially sealing engagement, with the wellbore string such
that the sealed interface is established, and (ii) the reservoir
fluid is being discharged into the reservoir fluid separation space
from the reservoir fluid discharge communicator such that the
gaseous depleted reservoir fluid is obtained in response to the
separation of the gaseous material from the discharged reservoir
fluid, bypassing of the gas-depleted reservoir fluid receiver, by
the gas-depleted reservoir fluid, is prevented or substantially
prevented.
3. The reservoir fluid production assembly as claimed in claim 2,
further comprising: a pump fluidly coupled to the gas-depleted
reservoir fluid discharge communicator for pressurizing the
discharged gas-depleted reservoir fluid; and a gas-depleted
reservoir fluid-producing conductor fluidly coupled to the pump for
conducting the pressurized gas-depleted reservoir fluid to the
surface.
4. The reservoir fluid production assembly as claimed in claim 1;
wherein the uppermost surface of the on-off tool is disposed within
the cavity.
5. The reservoir fluid production assembly as claimed in claim 1;
wherein at least 50% of the total volume of the on-off tool is
disposed within the cavity.
6. The reservoir fluid production assembly as claimed in claim 1;
wherein: the on-off tool includes a tool-based solid particulate
accumulation-susceptible region defined by that portion of the
outermost surface of the on-off tool that, while the assembly is
disposed within the wellbore, is facing uphole and is traversed by
a longitudinal axis of the wellbore; and at least 50% of the total
surface area of the tool-based solid particulate
accumulation-susceptible region is disposed within the cavity.
7. The reservoir fluid production assembly as claimed in claim 1;
wherein the disposition of the at least a portion of the on-off
tool within the cavity is with effect that the at least a portion
of the on-off tool is shielded, or substantially shielded, from
solid particulate matter within the reservoir fluid while the solid
particulate matter is being conducted from the reservoir fluid
separation space to the gas-depleted reservoir fluid receiver.
8. The reservoir fluid production assembly as claimed in claim 1;
wherein: the on-off tool includes an overshot and a stinger.
9. The reservoir fluid production assembly as claimed in claim 8;
wherein: the overshot and the stinger are co-operatively configured
such that, while the assembly is disposed within the wellbore, the
overshot is disposed uphole relative to the stinger.
10. The reservoir fluid production assembly as claimed in claim 9;
wherein the stinger is releasably connected to the overshot by one
or more frangible members.
11. The reservoir fluid production assembly as claimed in claim 10;
wherein the stinger includes one or more centralizers extending
laterally from the outermost surface of the stinger.
12. The reservoir fluid production assembly as claimed in claim 11;
wherein, for each one of the one or more centralizers,
independently, a centralizer-based solid particulate
accumulation-susceptible region is defined by that portion of the
outermost surface of the centralizer that, while the assembly is
disposed within the wellbore, is facing uphole and is traversed by
a longitudinal axis of the wellbore, and at least 50% of the total
surface area of the second solid particulate
accumulation-susceptible region has a normal axis that is disposed
at an acute angle of less than 45 degrees relative to the
longitudinal axis of the wellbore.
13. A system for producing hydrocarbon material from a reservoir
via a wellbore lined with a wellbore string, comprising: the
reservoir fluid production assembly as claimed in claim 1, disposed
within the wellbore such that the sealed interface is established,
and oriented such that, while the reservoir fluid is being
discharged into the reservoir fluid separation space from the
reservoir fluid discharge communicator such that the gaseous
depleted reservoir fluid is obtained in response to the separation
of the gaseous material from the discharged reservoir fluid, the
gas-depleted reservoir fluid receiver is disposed relative to the
reservoir fluid discharge communicator for receiving the
gas-depleted reservoir fluid obtained from the separation.
14. Parts for assembly of a reservoir fluid production assembly,
comprising: a flow diverter body including a cavity; wherein: the
flow diverter body defines a reservoir fluid receiver, a reservoir
fluid-conducting space, and a reservoir fluid discharge
communicator, wherein the reservoir fluid receiver, the reservoir
fluid-conducting space, and the reservoir fluid discharge
communicator are co-operatively configured such that, while
reservoir fluid is being received by the reservoir fluid receiver,
the reservoir fluid is conducted to the reservoir fluid discharge
communicator via the reservoir fluid-conducting space, and
discharged into a reservoir fluid separation space of the wellbore
from the reservoir fluid discharge communicator with effect that
gaseous material is separated from the discharged reservoir fluid
such that a gaseous depleted reservoir fluid is obtained; the flow
diverter body also defines a gas-depleted reservoir fluid receiver,
a gas-depleted reservoir fluid-conducting space, and a gas-depleted
reservoir fluid discharge communicator, wherein the gas-depleted
reservoir fluid receiver, the gas-depleted reservoir
fluid-conducting space, and the gas-depleted reservoir fluid
discharge communicator are co-operatively configured such that,
while reservoir fluid is being received by the gas-depleted
reservoir fluid receiver, the gas-depleted reservoir fluid is
conducted to the gas-depleted reservoir fluid discharge
communicator via the gas-depleted reservoir fluid-conducting space,
and discharged from the gas-depleted reservoir fluid discharge
communicator for supplying to a pump; and the flow diverter is
orientable such that, while the reservoir fluid is being discharged
into the reservoir fluid separation space from the reservoir fluid
discharge communicator such that the gaseous depleted reservoir
fluid is obtained in response to the separation of the gaseous
material from the discharged reservoir fluid, the gas-depleted
reservoir fluid receiver is disposed relative to the reservoir
fluid discharge communicator for receiving the gas-depleted
reservoir fluid obtained from the separation; a downhole-disposed
reservoir fluid-supplying conductor for receiving the reservoir
fluid from a downhole wellbore space; wherein: the flow diverter
body includes a first counterpart of an on-off tool; the
downhole-disposed reservoir fluid-supplying conductor includes a
second counterpart of the on-off tool; the first counterpart is
configured for interacting with the second counterpart such that
the on-off tool is obtained, and such that fluid coupling between
the reservoir fluid receiver and the downhole-disposed reservoir
fluid-supplying conductor is established for effecting conducting
of the received reservoir fluid to the reservoir fluid receiver;
and at least a portion of the first counterpart is disposed within
the cavity.
15. The parts for assembly as claimed in claim 14; wherein: the
interaction with the second counterpart, for which the first
counterpart is configured, establishes a joint; and the joint is
disposed within the cavity.
16. The parts for assembly reservoir fluid production assembly as
claimed in claim 15; wherein: at least 50% of the total volume of
the first counterpart is disposed within the cavity.
17. The parts for assembly reservoir fluid production assembly as
claimed in claim 16; wherein: the first counterpart includes a
first counterpart-based solid particulate accumulation-susceptible
region defined by that portion of the outermost surface of the
first counterpart that, while: (i) the first counterpart is
interacting with the second counterpart such that the on-off tool
is obtained, and (ii) the on-off tool is disposed within the
wellbore, is facing uphole and is traversed by a longitudinal axis
of the wellbore; and the disposition of the at least a portion of
the first counterpart within the cavity is such that at least 50%
of the total surface area of the first counterpart-based solid
particulate accumulation-susceptible region is disposed within the
cavity.
18. The parts for assembly as claimed in claim 17; wherein the
disposition of the at least a portion of the first counterpart
within the cavity is with effect that, while the assembly,
including the first counterpart, is disposed within the wellbore,
the at least a portion of the first counterpart is shielded, or
substantially shielded, from solid particulate matter within the
reservoir fluid while the solid particulate matter is being
conducted from the reservoir fluid separation space to the
gas-depleted reservoir fluid receiver.
19. The parts for assembly reservoir fluid production assembly as
claimed in claim 18; wherein: at least a portion of the on-off
tool, obtainable in response to the interaction with the second
counterpart, for which the first counterpart is configured, is
disposed within the cavity.
20. The parts for assembly as claimed in claim 14; wherein: the
first counterpart includes an overshot; and the second counterpart
includes a stinger.
21. The parts for assembly as claimed in claim 20; wherein the
stinger includes one or more centralizers extending laterally from
the outermost surface of the stinger.
22. A reservoir production assembly for disposition within a
wellbore that extends into a subterranean formation and is lined
with a wellbore string, wherein the reservoir production assembly
comprises: a flow diverter body including a cavity; wherein: the
flow diverter body defines a reservoir fluid receiver, a reservoir
fluid-conducting space, and a reservoir fluid discharge
communicator, wherein the reservoir fluid receiver, the reservoir
fluid-conducting space, and the reservoir fluid discharge
communicator are co-operatively configured such that, while
reservoir fluid is being received by the reservoir fluid receiver,
the reservoir fluid is conducted to the reservoir fluid discharge
communicator via the reservoir fluid-conducting space, and
discharged into a reservoir fluid separation space of the wellbore
from the reservoir fluid discharge communicator with effect that
gaseous material is separated from the discharged reservoir fluid
such that a gaseous depleted reservoir fluid is obtained; the flow
diverter body also defines a gas-depleted reservoir fluid receiver,
a gas-depleted reservoir fluid-conducting space, and a gas-depleted
reservoir fluid discharge communicator, wherein the gas-depleted
reservoir fluid receiver, the gas-depleted reservoir
fluid-conducting space, and the gas-depleted reservoir fluid
discharge communicator are co-operatively configured such that,
while reservoir fluid is being received by the gas-depleted
reservoir fluid receiver, the gas-depleted reservoir fluid is
conducted to the gas-depleted reservoir fluid discharge
communicator via the gas-depleted reservoir fluid-conducting space,
and discharged from the gas-depleted reservoir fluid discharge
communicator for supplying to a pump; and the flow diverter is
orientable such that, while the reservoir fluid is being discharged
into the reservoir fluid separation space from the reservoir fluid
discharge communicator such that the gaseous depleted reservoir
fluid is obtained in response to the separation of the gaseous
material from the discharged reservoir fluid, the gas-depleted
reservoir fluid receiver is disposed relative to the reservoir
fluid discharge communicator for receiving the gas-depleted
reservoir fluid obtained from the separation; a downhole-disposed
reservoir fluid-supplying conductor for receiving the reservoir
fluid from a downhole wellbore space and conducting the received
reservoir fluid to the reservoir fluid receiver; and a slideable
locking mechanism effecting releasable coupling of the reservoir
fluid receiver to the downhole-disposed reservoir fluid-supplying
conductor such that that fluid coupling of the flow diverter to the
downhole-disposed reservoir fluid-supplying conductor is effected;
wherein at least a portion of the slideable locking mechanism is
disposed within the cavity.
23. Parts for assembly of a reservoir fluid production assembly,
comprising: a flow diverter body including a cavity; wherein: the
flow diverter body defines a reservoir fluid receiver, a reservoir
fluid-conducting space, and a reservoir fluid discharge
communicator, wherein the reservoir fluid receiver, the reservoir
fluid-conducting space, and the reservoir fluid discharge
communicator are co-operatively configured such that, while
reservoir fluid is being received by the reservoir fluid receiver,
the reservoir fluid is conducted to the reservoir fluid discharge
communicator via the reservoir fluid-conducting space, and
discharged into a reservoir fluid separation space of the wellbore
from the reservoir fluid discharge communicator with effect that
gaseous material is separated from the discharged reservoir fluid
such that a gaseous depleted reservoir fluid is obtained; the flow
diverter body also defines a gas-depleted reservoir fluid receiver,
a gas-depleted reservoir fluid-conducting space, and a gas-depleted
reservoir fluid discharge communicator, wherein the gas-depleted
reservoir fluid receiver, the gas-depleted reservoir
fluid-conducting space, and the gas-depleted reservoir fluid
discharge communicator are co-operatively configured such that,
while reservoir fluid is being received by the gas-depleted
reservoir fluid receiver, the gas-depleted reservoir fluid is
conducted to the gas-depleted reservoir fluid discharge
communicator via the gas-depleted reservoir fluid-conducting space,
and discharged from the gas-depleted reservoir fluid discharge
communicator for supplying to a pump; and the flow diverter is
orientable such that, while the reservoir fluid is being discharged
into the reservoir fluid separation space from the reservoir fluid
discharge communicator such that the gaseous depleted reservoir
fluid is obtained in response to the separation of the gaseous
material from the discharged reservoir fluid, the gas-depleted
reservoir fluid receiver is disposed relative to the reservoir
fluid discharge communicator for receiving the gas-depleted
reservoir fluid obtained from the separation; a downhole-disposed
reservoir fluid-supplying conductor for receiving the reservoir
fluid from a downhole wellbore space; wherein: the flow diverter
body includes a first counterpart of a slideable locking mechanism;
the downhole-disposed reservoir fluid-supplying conductor includes
a second counterpart of the slideable locking mechanism; the first
counterpart is configured for interacting with the second
counterpart such that the slideable locking mechanism is obtained,
and such that fluid coupling between the reservoir fluid receiver
and the downhole-disposed reservoir fluid-supplying conductor is
established for effecting conducting of the received reservoir
fluid to the reservoir fluid receiver; and at least a portion of
the first counterpart is disposed within the cavity.
Description
FIELD
The present disclosure relates to mitigating downhole pump gas
interference, and the adverse effects of solid particulate matter
entrainment, during hydrocarbon production.
BACKGROUND
Downhole pump gas interference is a problem encountered while
producing wells, especially wells with horizontal sections. In
producing reservoir fluids containing a significant fraction of
gaseous material, the presence of such gaseous material hinders
production by contributing to sluggish flow. Additionally, solid
particulate material is entrained in reservoir fluids, and such
solid particulate matter can adversely affect production
operations.
SUMMARY
In one aspect, there is provided a reservoir production assembly
for disposition within a wellbore that extends into a subterranean
formation and is lined with a wellbore string, wherein the
reservoir production assembly comprises: a flow diverter body
including a cavity; wherein: the flow diverter body defines a
reservoir fluid receiver, a reservoir fluid-conducting space, and a
reservoir fluid discharge communicator, wherein the reservoir fluid
receiver, the reservoir fluid-conducting space, and the reservoir
fluid discharge communicator are co-operatively configured such
that, while reservoir fluid is being received by the reservoir
fluid receiver, the reservoir fluid is conducted to the reservoir
fluid discharge communicator via the reservoir fluid-conducting
space, and discharged into a reservoir fluid separation space of
the wellbore from the reservoir fluid discharge communicator with
effect that gaseous material is separated from the discharged
reservoir fluid such that a gaseous depleted reservoir fluid is
obtained; the flow diverter body also defines a gas-depleted
reservoir fluid receiver, a gas-depleted reservoir fluid-conducting
space, and a gas-depleted reservoir fluid discharge communicator,
wherein the gas-depleted reservoir fluid receiver, the gas-depleted
reservoir fluid-conducting space, and the gas-depleted reservoir
fluid discharge communicator are co-operatively configured such
that, while reservoir fluid is being received by the gas-depleted
reservoir fluid receiver, the gas-depleted reservoir fluid is
conducted to the gas-depleted reservoir fluid discharge
communicator via the gas-depleted reservoir fluid-conducting space,
and discharged from the gas-depleted reservoir fluid discharge
communicator for supplying to a pump; and the flow diverter is
orientable such that, while the reservoir fluid is being discharged
into the reservoir fluid separation space from the reservoir fluid
discharge communicator such that the gaseous depleted reservoir
fluid is obtained in response to the separation of the gaseous
material from the discharged reservoir fluid, the gas-depleted
reservoir fluid receiver is disposed relative to the reservoir
fluid discharge communicator for receiving the gas-depleted
reservoir fluid obtained from the separation; a downhole-disposed
reservoir fluid-supplying conductor for receiving the reservoir
fluid from a downhole wellbore space and conducting the received
reservoir fluid to the reservoir fluid receiver; and an on-off tool
effecting releasable coupling of the reservoir fluid receiver of
the flow diverter to the downhole-disposed reservoir
fluid-supplying conductor with effect that fluid coupling of the
flow diverter to the downhole-disposed reservoir fluid-supplying
conductor is effected; wherein at least a portion of the on-off
tool is disposed within cavity.
In another aspect, there is provided a system including the
assembly described immediately above, disposed within a
wellbore.
In another aspect, there is provided parts for assembly of a
reservoir fluid production assembly, comprising:
a flow diverter body including a cavity;
wherein: the flow diverter body defines a reservoir fluid receiver,
a reservoir fluid-conducting space, and a reservoir fluid discharge
communicator, wherein the reservoir fluid receiver, the reservoir
fluid-conducting space, and the reservoir fluid discharge
communicator are co-operatively configured such that, while
reservoir fluid is being received by the reservoir fluid receiver,
the reservoir fluid is conducted to the reservoir fluid discharge
communicator via the reservoir fluid-conducting space, and
discharged into a reservoir fluid separation space of the wellbore
from the reservoir fluid discharge communicator with effect that
gaseous material is separated from the discharged reservoir fluid
such that a gaseous depleted reservoir fluid is obtained; the flow
diverter body also defines a gas-depleted reservoir fluid receiver,
a gas-depleted reservoir fluid-conducting space, and a gas-depleted
reservoir fluid discharge communicator, wherein the gas-depleted
reservoir fluid receiver, the gas-depleted reservoir
fluid-conducting space, and the gas-depleted reservoir fluid
discharge communicator are co-operatively configured such that,
while reservoir fluid is being received by the gas-depleted
reservoir fluid receiver, the gas-depleted reservoir fluid is
conducted to the gas-depleted reservoir fluid discharge
communicator via the gas-depleted reservoir fluid-conducting space,
and discharged from the gas-depleted reservoir fluid discharge
communicator for supplying to a pump; and the flow diverter is
orientable such that, while the reservoir fluid is being discharged
into the reservoir fluid separation space from the reservoir fluid
discharge communicator such that the gaseous depleted reservoir
fluid is obtained in response to the separation of the gaseous
material from the discharged reservoir fluid, the gas-depleted
reservoir fluid receiver is disposed relative to the reservoir
fluid discharge communicator for receiving the gas-depleted
reservoir fluid obtained from the separation; a downhole-disposed
reservoir fluid-supplying conductor for receiving the reservoir
fluid from a downhole wellbore space; wherein: the flow diverter
body includes a first counterpart of an on-off tool; the
downhole-disposed reservoir fluid-supplying conductor includes a
second counterpart of the on-off tool; the first counterpart is
configured for interacting with the second counterpart such that
the on-off tool is obtained, and such that fluid coupling between
the reservoir fluid receiver and the downhole-disposed reservoir
fluid-supplying conductor is established for effecting conducting
of the received reservoir fluid to the reservoir fluid receiver;
and at least a portion of the first counterpart is disposed within
the cavity.
In another aspect, there is provided a reservoir production
assembly for disposition within a wellbore that extends into a
subterranean formation and is lined with a wellbore string, wherein
the reservoir production assembly comprises: a flow diverter body
including a cavity; wherein: the flow diverter body defines a
reservoir fluid receiver, a reservoir fluid-conducting space, and a
reservoir fluid discharge communicator, wherein the reservoir fluid
receiver, the reservoir fluid-conducting space, and the reservoir
fluid discharge communicator are co-operatively configured such
that, while reservoir fluid is being received by the reservoir
fluid receiver, the reservoir fluid is conducted to the reservoir
fluid discharge communicator via the reservoir fluid-conducting
space, and discharged into a reservoir fluid separation space of
the wellbore from the reservoir fluid discharge communicator with
effect that gaseous material is separated from the discharged
reservoir fluid such that a gaseous depleted reservoir fluid is
obtained; the flow diverter body also defines a gas-depleted
reservoir fluid receiver, a gas-depleted reservoir fluid-conducting
space, and a gas-depleted reservoir fluid discharge communicator,
wherein the gas-depleted reservoir fluid receiver, the gas-depleted
reservoir fluid-conducting space, and the gas-depleted reservoir
fluid discharge communicator are co-operatively configured such
that, while reservoir fluid is being received by the gas-depleted
reservoir fluid receiver, the gas-depleted reservoir fluid is
conducted to the gas-depleted reservoir fluid discharge
communicator via the gas-depleted reservoir fluid-conducting space,
and discharged from the gas-depleted reservoir fluid discharge
communicator for supplying to a pump; and the flow diverter is
orientable such that, while the reservoir fluid is being discharged
into the reservoir fluid separation space from the reservoir fluid
discharge communicator such that the gaseous depleted reservoir
fluid is obtained in response to the separation of the gaseous
material from the discharged reservoir fluid, the gas-depleted
reservoir fluid receiver is disposed relative to the reservoir
fluid discharge communicator for receiving the gas-depleted
reservoir fluid obtained from the separation; a downhole-disposed
reservoir fluid-supplying conductor for receiving the reservoir
fluid from a downhole wellbore space and conducting the received
reservoir fluid to the reservoir fluid receiver; and a slideable
locking mechanism effecting releasable coupling of the reservoir
fluid receiver to the downhole-disposed reservoir fluid-supplying
conductor such that that fluid coupling of the flow diverter to the
downhole-disposed reservoir fluid-supplying conductor is effected;
wherein at least a portion of the slideable locking mechanism is
disposed within the cavity.
In another aspect, there is provided a system including the
reservoir production assembly described immediately above, disposed
within a wellbore.
In another aspect, e is provided parts for assembly of a reservoir
fluid production assembly, comprising:
a flow diverter body including a cavity;
wherein: the flow diverter body defines a reservoir fluid receiver,
a reservoir fluid-conducting space, and a reservoir fluid discharge
communicator, wherein the reservoir fluid receiver, the reservoir
fluid-conducting space, and the reservoir fluid discharge
communicator are co-operatively configured such that, while
reservoir fluid is being received by the reservoir fluid receiver,
the reservoir fluid is conducted to the reservoir fluid discharge
communicator via the reservoir fluid-conducting space, and
discharged into a reservoir fluid separation space of the wellbore
from the reservoir fluid discharge communicator with effect that
gaseous material is separated from the discharged reservoir fluid
such that a gaseous depleted reservoir fluid is obtained; the flow
diverter body also defines a gas-depleted reservoir fluid receiver,
a gas-depleted reservoir fluid-conducting space, and a gas-depleted
reservoir fluid discharge communicator, wherein the gas-depleted
reservoir fluid receiver, the gas-depleted reservoir
fluid-conducting space, and the gas-depleted reservoir fluid
discharge communicator are co-operatively configured such that,
while reservoir fluid is being received by the gas-depleted
reservoir fluid receiver, the gas-depleted reservoir fluid is
conducted to the gas-depleted reservoir fluid discharge
communicator via the gas-depleted reservoir fluid-conducting space,
and discharged from the gas-depleted reservoir fluid discharge
communicator for supplying to a pump; and the flow diverter is
orientable such that, while the reservoir fluid is being discharged
into the reservoir fluid separation space from the reservoir fluid
discharge communicator such that the gaseous depleted reservoir
fluid is obtained in response to the separation of the gaseous
material from the discharged reservoir fluid, the gas-depleted
reservoir fluid receiver is disposed relative to the reservoir
fluid discharge communicator for receiving the gas-depleted
reservoir fluid obtained from the separation; a downhole-disposed
reservoir fluid-supplying conductor for receiving the reservoir
fluid from a downhole wellbore space; wherein: the flow diverter
body includes a first counterpart of a slideable locking mechanism;
the downhole-disposed reservoir fluid-supplying conductor includes
a second counterpart of the slideable locking mechanism; the first
counterpart is configured for interacting with the second
counterpart such that the slideable locking mechanism is obtained,
and such that fluid coupling between the reservoir fluid receiver
and the downhole-disposed reservoir fluid-supplying conductor is
established for effecting conducting of the received reservoir
fluid to the reservoir fluid receiver; and at least a portion of
the first counterpart is disposed within the cavity.
BRIEF DESCRIPTION OF DRAWINGS
The preferred embodiments will now be described with reference to
the following accompanying drawings:
FIG. 1 is a schematic illustration of an embodiment of a system of
the present disclosure;
FIG. 2 is a schematic illustration of a flow diverter of
embodiments of a reservoir production assembly of the present
disclosure;
FIG. 3 is a schematic illustration of a flow diverter body coupled
to an on/off tool of embodiments of a reservoir production assembly
of the present disclosure;
FIG. 4 is a sectional view of a portion of an embodiment of a
reservoir production assembly of the present disclosure,
illustrating the flow diverter body and the overshot;
FIG. 5 is an enlarged view of Detail "C" in FIG. 4;
FIG. 6 is an enlarged view of Detail "B" in FIG. 4;
FIG. 7 is a sectional view of an overshot of embodiments of a
reservoir production assembly of the present disclosure;
FIG. 8 is a perspective view of a housing of an overshot of
embodiments of a reservoir production assembly of the present
disclosure
FIG. 9 is a sectional view of the housing illustrated in FIG.
8;
FIG. 10 is a sectional view of the j-slot insert of a reservoir
production assembly of the present disclosure;
FIG. 11 is a perspective view of the j-slot insert illustrated in
FIG. 10; and
FIG. 12 is a perspective view of a stinger of a reservoir
production assembly of the present disclosure.
DETAILED DESCRIPTION
As used herein, the terms "up", "upward", "upper", or "uphole",
mean, relativistically, in closer proximity to the surface 106 and
further away from the bottom of the wellbore, when measured along
the longitudinal axis of the wellbore 102. The terms "down",
"downward", "lower", or "downhole" mean, relativistically, further
away from the surface 106 and in closer proximity to the bottom of
the wellbore 102, when measured along the longitudinal axis of the
wellbore 102.
Referring to FIGS. 1 and 2, there are provided systems 8, with
associated apparatuses, for producing hydrocarbons from a
reservoir, such as an oil reservoir, within a subterranean
formation 100, when reservoir pressure within the oil reservoir is
insufficient to conduct hydrocarbons to the surface 106 through a
wellbore 102.
The wellbore 102 can be straight, curved, or branched. The wellbore
102 can have various wellbore sections. A wellbore section is an
axial length of a wellbore 102. A wellbore section can be
characterized as "vertical" or "horizontal" even though the actual
axial orientation can vary from true vertical or true horizontal,
and even though the axial path can tend to "corkscrew" or otherwise
vary. In some embodiments, for example, the central longitudinal
axis of the passage 102CC of a horizontal section 102C is disposed
along an axis that is between about 70 and about 110 degrees
relative to the vertical "V", the central longitudinal axis of the
passage 102AA of a vertical section 102A is disposed along an axis
that is less than about 20 degrees from the vertical "V", and a
transition section 102B is disposed between the sections 102A and
102C. In some embodiments, for example, the transition section 102B
joins the sections 102A and 102C. In some embodiments, for example,
the vertical section 102A extends from the transition section 102B
to the surface 106.
"Reservoir fluid" is fluid that is contained within an oil
reservoir. Reservoir fluid may be liquid material, gaseous
material, or a mixture of liquid material and gaseous material. In
some embodiments, for example, the reservoir fluid includes water
and hydrocarbons, such as oil, natural gas condensates, or any
combination thereof.
Fluids may be injected into the oil reservoir through the wellbore
to effect stimulation of the reservoir fluid. For example, such
fluid injection is effected during hydraulic fracturing, water
flooding, water disposal, gas floods, gas disposal (including
carbon dioxide sequestration), steam-assisted gravity drainage
("SAGD") or cyclic steam stimulation ("CSS"). In some embodiments,
for example, the same wellbore is utilized for both stimulation and
production operations, such as for hydraulically fractured
formations or for formations subjected to CSS. In some embodiments,
for example, different wellbores are used, such as for formations
subjected to SAGD, or formations subjected to waterflooding.
A wellbore string 113 is employed within the wellbore 102 for
stabilizing the subterranean formation 100. In some embodiments,
for example, the wellbore string 113 also contributes to effecting
fluidic isolation of one zone within the subterranean formation 100
from another zone within the subterranean formation 100.
The fluid productive portion of the wellbore 102 may be completed
either as a cased-hole completion or an open-hole completion.
A cased-hole completion involves running wellbore casing down into
the wellbore through the production zone. In this respect, in the
cased-hole completion, the wellbore string 113 includes wellbore
casing.
The annular region between the deployed wellbore casing and the oil
reservoir may be filled with cement for effecting zonal isolation
(see below). The cement is disposed between the wellbore casing and
the oil reservoir for the purpose of effecting isolation, or
substantial isolation, of one or more zones of the oil reservoir
from fluids disposed in another zone of the oil reservoir. Such
fluids include reservoir fluid being produced from another zone of
the oil reservoir (in some embodiments, for example, such reservoir
fluid being flowed through a production tubing string disposed
within and extending through the wellbore casing to the surface),
or injected fluids such as water, gas (including carbon dioxide),
or stimulations fluids such as fracturing fluid or acid. In this
respect, in some embodiments, for example, the cement is provided
for effecting sealing, or substantial sealing, of flow
communication between one or more zones of the oil reservoir and
one or more others zones of the oil reservoir (for example, such as
a zone that is being produced). By effecting the sealing, or
substantial sealing, of such flow communication, isolation, or
substantial isolation, of one or more zones of the oil reservoir,
from another subterranean zone (such as a producing formation), is
achieved. Such isolation or substantial isolation is desirable, for
example, for mitigating contamination of a water table within the
oil reservoir by the reservoir fluid (e.g. oil, gas, salt water, or
combinations thereof) being produced, or the above-described
injected fluids.
In some embodiments, for example, the cement is disposed as a
sheath within an annular region between the wellbore casing and the
oil reservoir. In some embodiments, for example, the cement is
bonded to both of the production casing and the subterranean
formation 100.
In some embodiments, for example, the cement also provides one or
more of the following functions: (a) strengthens and reinforces the
structural integrity of the wellbore, (b) prevents, or
substantially prevents, produced reservoir fluid of one zone from
being diluted by water from other zones. (c) mitigates corrosion of
the wellbore casing, (d) at least contributes to the support of the
wellbore casing, and e) allows for segmentation for stimulation and
fluid inflow control purposes.
The cement is introduced to an annular region between the wellbore
casing and the subterranean formation 100 after the subject
wellbore casing has been run into the wellbore 102. This operation
is known as "cementing".
In some embodiments, for example, the wellbore casing includes one
or more casing strings, each of which is positioned within the well
bore, having one end extending from the well head. In some
embodiments, for example, each casing string is defined by jointed
segments of pipe. The jointed segments of pipe typically have
threaded connections.
Typically, a wellbore contains multiple intervals of concentric
casing strings, successively deployed within the previously run
casing. With the exception of a liner string, casing strings
typically run back up to the surface 106. Typically, casing string
sizes are intentionally minimized to minimize costs during well
construction. Generally, smaller casing sizes make production and
artificial lifting more challenging.
For wells that are used for producing reservoir fluid, few of these
actually produce through wellbore casing. This is because producing
fluids can corrode steel or form undesirable deposits (for example,
scales, asphaltenes or paraffin waxes) and the larger diameter can
make flow unstable. In this respect, a production string is usually
installed inside the last casing string. The production string is
provided to conduct reservoir fluid, received within the wellbore,
to the wellhead 116. In some embodiments, for example. the annular
region between the last casing string and the production tubing
string may be sealed at the bottom by a packer.
The wellbore 102 is disposed in flow communication (such as through
perforations provided within the installed casing or liner, or by
virtue of the open hole configuration of the completion), or is
selectively disposable into flow communication (such as by
perforating the installed casing, or by actuating a valve to effect
opening of a port), with the subterranean formation 100. When
disposed in flow communication with the subterranean formation 100,
the wellbore 102 is disposed for receiving reservoir fluid flow
from the subterranean formation 100, with effect that the system 8
receives the reservoir fluid.
In some embodiments, for example, the wellbore casing is set short
of total depth. Hanging off from the bottom of the wellbore casing,
with a liner hanger or packer, is a liner string. The liner string
can be made from the same material as the casing string, but,
unlike the casing string, the liner string does not extend back to
the wellhead 116. Cement may be provided within the annular region
between the liner string and the oil reservoir for effecting zonal
isolation (see below), but is not in all cases. In some
embodiments, for example, this liner is perforated to effect flow
communication between the reservoir and the wellbore. In this
respect, in some embodiments, for example, the liner string can
also be a screen or is slotted. In some embodiments, for example,
the production tubing string may be engaged or stung into the liner
string, thereby providing a fluid passage for conducting the
produced reservoir fluid to the wellhead 116. In some embodiments,
for example, no cemented liner is installed, and this is called an
open hole completion or uncemented casing completion.
An open-hole completion is effected by drilling down to the top of
the producing formation, and then lining the wellbore (such as, for
example, with a wellbore string 113). The wellbore is then drilled
through the producing formation, and the bottom of the wellbore is
left open (i.e. uncased), to effect flow communication between the
reservoir and the wellbore. Open-hole completion techniques include
bare foot completions, pre-drilled and pre-slotted liners, and
open-hole sand control techniques such as stand-alone screens, open
hole gravel packs and open hole expandable screens. Packers and
casing can segment the open hole into separate intervals and ported
subs can be used to effect flow communication between the reservoir
and the wellbore.
The system 8 includes a production string assembly 10 disposed
within a wellbore 102 that is lined with a wellbore string 113. The
production string assembly 10 includes a separator assembly 600,
and a gas-depleted reservoir fluid production assembly 300
including a pump 302 and a gas-depleted reservoir fluid-producing
conductor 204.
The assembly 10 is disposed within the wellbore string 113, such
that an intermediate wellbore passage 112 is defined within the
wellbore string 113, between the assembly 10 and the wellbore
string 113. In some embodiments, for example, the intermediate
wellbore passage 112 is an annular space disposed between the
assembly 10 and the wellbore string 113. In some embodiments, for
example, the intermediate wellbore passage 112 is defined by the
space that extends outwardly, relative to the central longitudinal
axis of the assembly 10, from the assembly 10 to the wellbore fluid
conductor 113. In some embodiments, for example, the intermediate
wellbore passage 112 extends longitudinally to the wellhead 116,
between the assembly 10 and the wellbore string 113.
The separator assembly 600 and the wellbore string 113 are
co-operatively configured for effecting supply of reservoir fluid,
which has been received within a downhole-disposed wellbore space
110 of the wellbore 102 from the subterranean formation, to a
reservoir fluid separation space 112X that is disposed within an
uphole-disposed wellbore space 108 of the wellbore 102 such that
gaseous material is separated from the reservoir fluid in response
to buoyancy forces to obtain a gas-depleted reservoir fluid, and
are also co-operatively configured for supplying the gas-depleted
reservoir fluid to the pump 302. By effecting such separation, gas
lock of the pump 302 is mitigated.
In some embodiments, for example, the separator assembly 600 and
the wellbore string 113 are co-operatively configured such that,
while the separator assembly 600 is disposed within the wellbore
string 113, a reservoir fluid conductor 6002 is defined for
conducting reservoir fluid that is received within a downhole
wellbore space from the subterranean formation 100, to the
reservoir fluid separation space 112X of the wellbore 102, with
effect that a gas-depleted reservoir fluid is separated from the
reservoir fluid within the reservoir fluid separation space 112X in
response to at least buoyancy forces, and a gas-depleted reservoir
fluid conductor 6004 is also defined for receiving the separated
gas-depleted reservoir fluid (while the separated gas-depleted
reservoir fluid is flowing in a downhole direction), and diverting
the flow of the received gas-depleted reservoir fluid such that the
received gas-depleted reservoir fluid is conducted by the separator
assembly 600 to the pump 302.
In some embodiments, for example, the reservoir fluid conductor
6002 and the reservoir fluid separation space 112X are
co-operatively configured such that, in operation, while the
reservoir fluid is being supplied to the reservoir fluid separation
space 112X via the reservoir fluid conductor 6002, the velocity of
the gaseous portion of the reservoir fluid being conducted via the
reservoir fluid conductor 6002 is greater than the critical liquid
lifting velocity, and while the reservoir fluid is disposed within
the reservoir fluid separation space 112X, the velocity of the
gaseous portion of the reservoir fluid is sufficiently low such
that the above-described separation is effected. In this respect,
in some embodiments, for example, the ratio of the minimum
cross-sectional flow area of the reservoir fluid separation space
112X to the maximum cross-sectional flow area of the reservoir
fluid conductor 6002 is at least about 1.5.
The separator assembly 600 is fluidly coupled to the pump 302 via a
conduit 303 for effecting the supplying of the gas-depleted
reservoir fluid to the pump 302. The pump 302 is provided to,
through mechanical action, pressurize and effect conduction of the
gas-depleted reservoir fluid to the surface 106, and thereby effect
production of the gas-depleted reservoir fluid. In some
embodiments, for example, the pump 302 is a sucker rod pump. Other
suitable pumps 302 include screw pumps, electrical submersible
pumps, jet pumps, and plunger lift. The gas-depleted reservoir
fluid-producing conductor 204 is fluidly coupled to the pump 302
for conducting the pressurized gas-depleted reservoir fluid to the
surface 106.
The separator assembly 600 includes a flow diverter body 602A. The
flow diverter body 602A is co-operatively disposed relative to the
wellbore string 113 such that a flow diverter body-defined
intermediate passage 6021 (such as, for example, an annular fluid
passage) is disposed between the flow diverter body 602A and the
wellbore string 113. The flow diverter body-defined intermediate
passage 6021 forms part of the intermediate wellbore passage 112.
In some embodiments, for example, the flow diverter body 602A is
disposed within a vertical portion of the wellbore 102 that extends
to the surface 106. An exemplary flow diverter body is illustrated
in published International Application No. PCT/CA2015/000178.
The flow diverter body 602A defines a reservoir fluid-conducting
space 6022 that defines a portion of the reservoir fluid conductor
6002. In some embodiments, for example, the reservoir
fluid-conducting space 6022 includes one or more passages. In those
embodiments where the reservoir fluid-conducting space 6022
includes a plurality of passages, in some of these embodiments, for
example, two or more of the passages are interconnected. In those
embodiments where the reservoir fluid-conducting space 6022
includes a plurality of passages, in some of these embodiments, for
example, there is an absence of interconnection between at least
some of the passages. The flow diverter body 602A also defines a
reservoir fluid receiver 6023 for receiving reservoir fluid within
the flow diverter body 602A and a reservoir fluid discharge
communicator 6024 for discharging reservoir fluid from the flow
diverter body 602A into the reservoir fluid separation space 112X.
The reservoir fluid receiver 6023 is fluidly coupled to the
reservoir fluid discharge communicator 6024 via the reservoir
fluid-conducting space 6022. In some embodiments, for example, the
reservoir fluid receiver 6023 includes one or more ports. In some
embodiments, for example, the reservoir fluid discharge
communicator 6024 includes one or more ports. In some embodiments,
for example, the flow diverter 602 is disposed within the wellbore
102 such that the reservoir fluid receiver 6023 is disposed
downhole relative to the reservoir fluid discharge communicator
6024.
Referring to FIG. 2, in some embodiments, for example, the
reservoir fluid discharge communicator 6024 is oriented such that,
a ray (see, for example ray 6024A), that is disposed along the
central longitudinal axis of the reservoir fluid discharge
communicator 6024, is disposed in an uphole direction at an acute
angle of less than 30 degrees relative to the central longitudinal
axis of the wellbore portion within which the flow diverter body
602A is disposed.
The flow diverter body 602A also defines a gas-depleted reservoir
fluid-conducting space 6025 that defines a portion of the
gas-depleted reservoir fluid conductor 6004. In some embodiments,
for example, the gas-depleted reservoir fluid-conducting space 6025
includes one or more passages. In those embodiments where the
reservoir fluid-conducting space 6025 includes a plurality of
passages, in some of these embodiments, for example, two or more of
the passages are interconnected. In those embodiments where the
reservoir fluid-conducting space 6025 includes a plurality of
passages, in some of these embodiments, for example, there is an
absence of interconnection between at least some of the passages.
The flow diverter body 602A also defines a gas-depleted reservoir
fluid receiver 6026 for receiving gas-depleted reservoir fluid
within the flow diverter body 602A and a gas-depleted reservoir
fluid discharge communicator 6027 for discharging gas-depleted
reservoir fluid from the flow diverter body 602A for supplying to
the pump 302. The gas-depleted reservoir fluid receiver 6026 is
fluidly coupled to the gas-depleted reservoir fluid discharge
communicator 6027 via the gas-depleted reservoir fluid-conducting
space 6025. In some embodiments, for example, the gas-depleted
reservoir fluid receiver 6026 includes one or more ports. In some
embodiments, for example, the gas-depleted reservoir fluid
discharge communicator 6027 includes one or more ports. The flow
diverter 602 is disposed within the wellbore 102 such that the
gas-depleted reservoir fluid receiver 6026 is disposed downhole
relative to the gas-depleted reservoir fluid discharge communicator
6027.
The system 8 receives, via the wellbore 102, the reservoir fluid
flow from the reservoir 100. As discussed above, the wellbore 102
is disposed in flow communication (such as through perforations
provided within the installed casing or liner, or by virtue of the
open hole configuration of the completion), or is selectively
disposable into flow communication (such as by perforating the
installed casing, or by actuating a valve to effect opening of a
port), with the subterranean formation 100. When disposed in flow
communication with the subterranean formation 100, the wellbore 102
is disposed for receiving reservoir fluid flow from the
subterranean formation 100, with effect that the system 8 receives
the reservoir fluid.
In this respect, the separator assembly 600 also includes a
reservoir fluid-supplying conductor 202A for conducting the
reservoir fluid, which is received within a downhole-disposed
wellbore space 110 of the wellbore 102, from the downhole-disposed
wellbore space 110 and uphole to the reservoir fluid receiver 6023
of the flow diverter body 602A. In this respect, the reservoir
fluid-supplying conductor 202A defines a portion of the reservoir
fluid conductor 6002, and the reservoir fluid-supplying conductor
202A and the flow diverter body 602A are co-operatively configured
such that, while reservoir fluid is being received within the
downhole-disposed wellbore space 110, the reservoir fluid is
conducted uphole from the downhole-disposed wellbore space 110 to
the reservoir fluid separation space 112X via at least the
reservoir fluid-supplying conductor 202A, the reservoir fluid
receiver 6023, the reservoir fluid-conducting space 6022, and the
reservoir fluid discharge communicator 6024.
In some embodiments, for example, the ratio of the minimum
cross-sectional flow area of the reservoir fluid separation space
112X to the maximum cross-sectional flow area of the reservoir
fluid-supplying conductor 202A is at least about 1.5. In this
respect, in some embodiments, for example, the reservoir
fluid-supplying conductor 202A defines a velocity string, and the
maximum cross-sectional flow area of the velocity string is less
than the minimum cross-sectional flow area of the gas-depleted
reservoir fluid-producing conductor 204.
In some embodiments, for example, the length of the reservoir
fluid-supplying conductor 202A, as measured along the central
longitudinal axis of the reservoir fluid-supplying conductor 202A,
is at least 500 feet, such as, for example, at least 750 feet, such
as, for example at least 1000 feet. In some of these embodiments,
for example, the reservoir fluid-supplying conductor 202A includes
a receiver 206 (e.g. an inlet port) for receiving the reservoir
fluid from the downhole wellbore space 110, and the receiver 206 is
disposed within the horizontal section 102C of the wellbore
102.
As above-described, reservoir fluid is discharged into the
reservoir fluid separation space 112X from the reservoir fluid
discharge communicator 6024. In this respect, in some embodiments,
for example, the reservoir fluid separation space 112X is disposed
uphole relative to the reservoir fluid discharge communicator 6024.
While reservoir fluid is disposed within the reservoir fluid
separation space 112X, after having been discharged from the
reservoir fluid discharge communicator 6024, gas-depleted reservoir
fluid is separated from the reservoir fluid within the reservoir
fluid separation space 112X in response to at least buoyancy forces
such that a gas-depleted reservoir fluid and a liquid-depleted
reservoir fluid are obtained.
The gas-depleted reservoir fluid receiver 6026 is disposed in flow
communication with the reservoir fluid separation space 112X via
the flow diverter body-defined intermediate passage 6021 for
receiving the separated gas-depleted reservoir fluid. In this
respect, the gas-depleted reservoir fluid receiver 6026 is disposed
downhole relative to the reservoir fluid separation space 112X. In
some embodiments, for example, the gas-depleted reservoir fluid
receiver 6026 is also disposed downhole relative to the reservoir
fluid discharge communicator 6024. For preventing, or substantially
preventing, bypassing of the gas-depleted reservoir fluid receiver
6026 by gas-depleted reservoir fluid that has been separated from
the reservoir fluid within the reservoir fluid separation space
112X, the system 8 also includes a sealed interface 500 for
preventing, or substantially preventing, bypassing of the
gas-depleted reservoir fluid receiver 6026 by gas-depleted
reservoir fluid that has been separated from the reservoir fluid
within the reservoir fluid separation space 112X. In some
embodiments, for example, establishing of the sealed interface 500
is effected by a sealed interface effector 502 of the separator
assembly 600, such as, for example, a packer, while the sealed
interface effector 502 is disposed in sealing engagement, or
substantially sealing engagement, with the wellbore string 113.
In some embodiments, for example, the sealed interface 500 is
defined within the wellbore 102, between: (a) an uphole wellbore
space 108 of the wellbore 102 (the uphole wellbore space 108
including the reservoir fluid separation space 112X), and (b) the
downhole wellbore space 110 of the wellbore 102. In some
embodiments, for example, the disposition of the sealed interface
500 is such that flow communication, via the intermediate wellbore
passage 112, between the uphole wellbore space 108 and the downhole
wellbore space 110 (and across the sealed interface 500), is
prevented, or substantially prevented. In some embodiments, for
example, the disposition of the sealed interface 500 is such that
fluid flow, across the sealed interface 500, in a downhole
direction, from the uphole wellbore space 108 to the downhole
wellbore space 110, is prevented, or substantially prevented. In
this respect, the sealed interface 500 functions to prevent, or
substantially prevent, gas-depleted reservoir fluid flow, that is
separated from the reservoir fluid within the reservoir fluid
separation space 112X, from bypassing the gas-depleted reservoir
fluid receiver 6026, and, as a corollary, the gas-depleted
reservoir fluid is directed to the gas-depleted reservoir fluid
receiver 6026 for effecting supply of the gas-depleted reservoir
fluid to the pump 302.
Referring to FIG. 1, in some embodiments, for example, the sealed
interface 500 is disposed within a section of the wellbore 102
whose axis 14A is disposed at an angle ".alpha." of at least 60
degrees relative to the vertical "V". In some of these embodiments,
for example, the sealed interface 500 is disposed within a section
of the wellbore whose axis is disposed at an angle "60 " of at
least 85 degrees relative to the vertical "V". In this respect,
disposing the sealed interface 500 within a wellbore section having
such wellbore inclinations minimizes solid debris accumulation at
the sealed interface 500.
In some embodiments, for example, the reservoir fluid-supplying
conductor 202A, the flow diverter body 602A, the sealed interface
500, and the pump 302 are co-operatively configured such that,
while the reservoir fluid-supplying conductor 202A is receiving
reservoir fluid, from the downhole wellbore space 110, that has
been received within the downhole wellbore space 110 from the
subterranean formation 100: the reservoir fluid is supplied to the
reservoir fluid separation space 112X via the reservoir fluid
receiver 6023, the reservoir fluid-conducting space 6022, and the
reservoir fluid discharge communicator 6024; within the reservoir
fluid separation space 112X, a gas-depleted reservoir fluid is
separated from the supplied reservoir fluid, in response to at
least buoyancy forces, such that the gas-depleted reservoir fluid
is obtained; bypassing of the gas-depleted reservoir fluid receiver
6026 by the gas-depleted reservoir fluid, is prevented, or
substantially prevented, by the sealed interface 500 such that the
gas-depleted reservoir fluid is received by the gas-depleted
reservoir fluid receiver 6026; and the received gas-depleted
reservoir fluid is supplied to the pump 302.
Once received by the pump 302, the gas-depleted reservoir fluid is
pressurized by the pump 302 and conducted as a flow 402 to the
surface via the gas-depleted reservoir fluid-producing conductor
204. In this respect, the gas-depleted reservoir fluid-producing
conductor 204 extends from the pump 302 to the wellhead 116 for
effecting flow communication between the pump 302 and the earth's
surface 106, such as, for example, a collection facility located at
the earth's surface 106. In some embodiments, for example, the
minimum cross-sectional flow area of the gas-depleted reservoir
fluid-producing conductor 204 is greater than the maximum
cross-sectional flow area of the reservoir fluid-supplying
conductor 202A. In some embodiments, for example, the ratio of the
cross-sectional flow area of the conductor 204 to the
cross-sectional flow area of the conductor 202A is at least 1.1,
such as, for example, at least 1.25, such as, for example, at least
1.5.
In parallel, the separation of gaseous material from the reservoir
fluid is with effect that a liquid-depleted reservoir fluid is
obtained and is conducted uphole (in the gaseous phase, or at least
primarily in the gaseous phase with relatively small amounts of
entrained liquid) as a flow 404 via the intermediate wellbore
passage 112 that is disposed between the assembly 10 and the
wellbore string 113 (see above).
The reservoir fluid produced from the subterranean formation 100,
via the wellbore 102, including the gas-depleted reservoir fluid,
the liquid-depleted reservoir material, or both, may be discharged
through the wellhead 116 to a collection facility, such as a
storage tank within a battery.
In some embodiments, for example, the uphole-disposed wellbore
space 108 includes a sump space 700, and the sump space 700 is
disposed: (i) downhole relative to the gas-depleted reservoir fluid
receiver 6026, and (ii) uphole relative to the sealed interface
500. The sump space 700 is provided for collecting solid
particulate material that gravity separates from the reservoir
fluid that is supplied to the reservoir fluid separation space
112X. In some embodiments, for example, the gas-depleted reservoir
fluid receiver 6026 is oriented in a downhole direction such that
the gas-depleted reservoir fluid, that is flowing downhole to the
gas-depleted reservoit fluid receiver 6026 via the flow diverter
body-defined intermediate passage 6021, prior to being received by
the gas-depleted reservoir fluid receiver 6026, reverses direction
and flows in an uphole direction into the gas-depleted reservoir
fluid receiver 6026. During the flow reversal, separation of at
least a fraction of solid particulate material, that is entrained
within the gas-depleted reservoir fluid, from the reservoir fluid
is encouraged, resulting in gravity settling of the separated solid
particulate material within the sump space
In some embodiments, for example, at least a fraction of the sump
space 700 is disposed within the vertical section 102A of the
wellbore 102. In some embodiments, for example, at least a majority
of the sump space 700 is disposed within the vertical section 102A
of the wellbore 102. In some embodiments, for example, the sump
space 700 has a volume of at least 0.1 m.sup.3. In some
embodiments, for example, the volume is at least 0.5 m.sup.3. In
some embodiments, for example, the volume is at least 1.0 m.sup.3.
In some embodiments, for example, the volume is at least 3.0
m.sup.3. By providing for the sump space 700, a suitable space is
provided for collecting relative large volumes of solid debris that
has separated from the reservoir fluid, such that interference by
the accumulated solid debris with the production of oil through the
system is mitigated. This increases the run-time of the system
before any maintenance is required.
The reservoir fluid receiver 6023 of the flow diverter body 602A is
fluidly coupled to the reservoir fluid-supplying conductor 202A via
a releasable locking mechanism 800 that effects releasable locking
of the flow diverter body 602A to the reservoir fluid-supplying
conductor 202A. The releasable locking mechanism 800 is at least
partially disposed within a cavity 640 of the flow diverter body
602A. In some embodiments, for example, the entirety, or the
substantial entirety, of the releasable locking mechanism 800 is
disposed within the cavity 640. In disposing the releasable
connector 800, relative to the flow diverter body 602A, in the
manner above-described, accumulation of solid debris relative to
the releasable connector 800, which could interfere with release of
the flow diverter body 602A from the reservoir fluid-supplying
conductor 202A, is mitigated. In this respect, the assembly 10
further includes the releasable locking mechanism 800.
In this respect, a releasably connectible uphole production
assembly 601, including a releasably connectible flow diverter body
602 that is fluidly coupled to the gas-depleted reservoir fluid
production assembly 300 for supplying gas-depleted reservoir fluid
to the gas-depleted reservoir fluid production assembly 300, is
provided. The releasably connectible flow diverter body 602
includes the flow diverter body 602A and a first locking mechanism
counterpart 802. Correspondingly, a releasably connectible downhole
production assembly 202 is provided, and the releasably connectible
downhole production assembly 202 includes the reservoir
fluid-supplying conductor 202A and a second locking mechanism
counterpart 804. The releasable connection of the flow diverter
body 602A to the reservoir fluid supplying conductor 202A is
effected by releasable connection of the first and second connector
counterparts 802, 804, and the releasable connection of the first
and second connector counterparts 802, 804 establishes fluid
communication between the reservoir fluid receiver 623 of the flow
diverter body 602A and the reservoir fluid-supplying conductor
202A. In some embodiments, for example, the releasable locking
mechanism 800 is a slidable locking mechanism and, in this respect,
the connection and disconnection is effected by slidable movement
of first counterpart 802 relative to the second connector
counterpart 804. In some embodiments, for example, the slidable
movement includes a rotational component.
For establishing this fluid communication, the first locking
mechanism counterpart 802 includes an internal surface that defines
a passage that is disposed in flow communication with the reservoir
fluid receiver 623 of the flow diverter body 602A, and the second
locking mechanism counterpart 804 includes an internal surface that
defines a passage that is disposed in flow communication with the
reservoir fluid-supplying conductor 202A.
In some embodiments, for example, the releasable locking mechanism
800 includes an on-off tool 806, and the on-off tool 806 is at
least partially disposed within the cavity 640.
In this respect, in some embodiments, for example, the uppermost
surface 806A of the on-off tool 806 is disposed within the cavity
640. In some embodiments, for example, wherein at least 50% of the
total volume, such as, for example, at least 60% of the total
volume of the on-off tool 806, such as, for example, at least 70%
of the total volume of the on-off tool 806, such as, for example,
at least 80% of the total volume of the on-off tool 806 is disposed
within the cavity 640. In some embodiments, for example, the on-off
tool 806 includes a tool-based solid particulate
accumulation-susceptible region 806B defined by that portion of the
outermost surface of the on-off tool 806 that, while the assembly
10 is disposed within the wellbore 102, is facing uphole and is
traversed by a longitudinal axis of the wellbore 102, and at least
50% of the total surface area of the tool-based solid particulate
accumulation-susceptible region 806B, such as, for example, at
least 60% of the total surface area of the tool-based solid
particulate accumulation-susceptible region 806B, such as, for
example, at least 70% of the total surface area of the tool-based
solid particulate accumulation-susceptible region 806B, such as,
for example, at least 80% of the total surface area of the
tool-based solid particulate accumulation-susceptible region 806B,
is disposed within the cavity 640. In some embodiments, for
example, the disposition of the at least a portion of the on-off
tool 806 within the cavity 640 is with effect that the at least a
portion of the on-off tool 806 is shielded, or substantially
shielded, from solid particulate matter within the reservoir fluid
while the solid particulate matter is being conducted from the
reservoir fluid separation space 112X to the gas-depleted reservoir
fluid receiver 6026.
In some embodiments, for example, at least a portion of the first
counterpart 802 is disposed within the cavity 640. Referring to
FIG. 6, in some embodiments, for example, the interaction with the
second counterpart 804, for which the first counterpart 802 is
configured, establishes a joint 803, wherein the joint 803 is
disposed within the cavity 640. In some embodiments, for example,
at least 50% of the total volume of the first counterpart 802, such
as, for example, at least 60% of the total volume of the first
counterpart 802, such as, for example, at least 70% of the total
volume of the first counterpart 802, such as, for example, at least
80% of the total volume of the first counterpart 802, is disposed
within the cavity 640. In some embodiments, for example, the first
counterpart 802 includes a first counterpart-based solid
particulate accumulation-susceptible region 802A defined by that
portion of the outermost surface of the first counterpart 802 that,
while: (i) the first counterpart 802 is interacting with the second
counterpart 804 such that the on-off tool 806 is obtained, and (ii)
the on-off tool 806 is disposed within the wellbore 102, is facing
uphole and is traversed by a longitudinal axis of the wellbore 102,
and the disposition of the at least a portion of the first
counterpart 802 within the cavity 640 is such that at least 50% of
the total surface area of the first counterpart-based solid
particulate accumulation-susceptible region 802A, such as, for
example, at least 60% of the total surface area of the first
counterpart-based solid particulate accumulation-susceptible region
802A, such as, for example, at least 70% of the total surface area
of the first counterpart-based solid particulate
accumulation-susceptible region 802A, such as, for example, at
least 80% of the total surface area of the first counterpart-based
solid particulate accumulation-susceptible region 802A is disposed
within the cavity 640. In some embodiments, for example, the
disposition of the at least a portion of the first counterpart 802
within the cavity 640 is with effect that, while the assembly 10
including the first counterpart 802, is disposed within the
wellbore 102, the at least a portion of the first counterpart 802
is shielded, or substantially shielded, from solid particulate
matter within the reservoir fluid while the solid particulate
matter is being conducted from the reservoir fluid separation space
112X to the gas-depleted reservoir fluid receiver 6026.
Referring to FIG. 3, in some embodiments, for example, the on-off
tool 806 includes an overshot 808 and a stinger 810. In this
respect, the first locking mechanism counterpart 802 includes the
overshot 808 and the second locking mechanism counterpart 804
includes the stinger 810. Referring to FIGS. 4 to 6, the overshot
808 is configured to receive insertion of the stinger 810 for
effecting the releasable connection of the flow diverter body 602A
to the reservoir fluid-supplying conductor 202A such that fluid
coupling of the reservoir fluid receiver 623 with the reservoir
fluid-supplying conductor 202A is established. In this respect, the
stinger 810 includes a fluid passage 810A for receiving and
conducting reservoir fluid that is being conducted by the reservoir
fluid-supplying conductor 202A. Relatedly, the overshot 808
includes a passage 808A that is configured to receive insertion of
the stinger 810, and is co-operatively configured with the stinger
810 such that, while the stinger 810 is disposed within the passage
808A, the passage 808A is disposed for receiving and conducting
reservoir fluid being conducted by the releasably connectible
downhole production assembly 202.
In some embodiments, for example, the overshot 808 defines a j-slot
812, and the stinger 810 includes one or more lugs 814, and the
overshot 808 and the stinger 810 are co-operatively configured such
that, in response to insertion of the stinger 810 within the
overshot 808, the lugs 814 are received within the j-slot 812 (see
FIG. 6) for effecting the releasable connection of the flow
diverter body 602A to the reservoir fluid supplying conductor
202A.
In some embodiments, for example, the overshot 808 and the stinger
810 are co-operatively configured such that, while the overshot 808
is releasably coupled to the stinger 810, a sealed interface 816 is
defined (such as, for example, a sealing member 816A) for
preventing, or substantially preventing, bypassing of the fluid
passage of the overshot 808 by material that is flowing through the
fluid passage of the stinger 810 in the uphole direction, such as
by egress of material being conducted by the fluid passage, across
a joint between the overshot 808 and the stinger 810. In some
embodiments, for example, the release of the overshot 808 from the
releasable coupling to the stinger 810, is with effect that the
sealed interface 816 is defeated. In some embodiments, for example,
the sealed interface 816 is defined by a sealing engagement, or
substantially sealing engagement, between the overshot 808 and the
stinger 810 and, in this respect, is effected by a sealing member
818 that is carried within the housing 820 of the overshot 808.
Referring to FIG. 7, in some embodiments, for example, the overshot
808 is an assembly including the housing 820 and a top sub 822. The
housing 820 is threaded to the top sub 822. Referring to FIGS. 8
and 9, the housing 820 includes a body 824 and a j-slot defining
insert 826 (see FIGS. 10 and 11) that defines the j-slot 812. The
j-slot defining insert 826 is received within a receptacle of the
body 824 and fastened to the body 824 with fasteners 826A, 826B,
and 826C.
In some embodiments, for example, the overshot 808 is connected
(such as, for example, threadably connected) to the flow diverter
body 602A via a connector (including for example, a tube joint 828
and a cross-over sub 830) such that flow communication between the
passage 808A and the reservoir fluid receiver 6023 is effected,
thereby enabling conduction of reservoir fluid, being received
within the wellbore 102, to the flow diverter body 602A.
In some embodiments, for example, the flow diverter body 602A
includes a shroud assembly 832 depending from a main body 834 for
defining the cavity 640 within which the releasable locking
mechanism 800 is at least partially disposed, as above-described.
In the illustrated embodiment, for example, the shroud assembly 832
is assembled by coupling of an upper shroud 832A to a lower shroud
832B via a slip joint. In some embodiments, for example, the upper
shroud 832A is connected to the flow diverter body 602A with
suitable fasteners, and the lower shroud is connected to the
overshot 808 (such as, for example the housing 820) with suitable
fasteners 834 In some embodiments, for example, the space 836 (for
example, an annular space), between the shroud assembly 832 and the
assembly of the cross-over sub 830, the tube joint 808, and the
overshot 808, defines a portion of the gas-depleted reservoir
fluid-conducting space 6025, and the downhole terminus of the
shroud assembly 832 defines the gas-depleted reservoir fluid
receiver 6026. In some embodiments, for example, channels 838 are
defined within the exterior surface of the housing 820 for
facilitating flow of the gas-depleted reservoir fluid through the
space 836 between the shroud assembly 832 and the overshot 808.
Referring to FIG. 12, in some embodiments, for example, the stinger
810 is in the form of a mandrel 810B that defines the fluid passage
810A and carries the lugs 814. In some embodiments, for example,
one or more centralizers 838 extend radially from the outermost
surface of the mandrel 810A for centralizing the stinger 810
relative to the wellbore 102, and thereby facilitating its
insertion into the overshot 808. In some embodiments, for example,
for each one of the centralizers 838, independently, a solid
particulate accumulation-susceptible region 840 is defined by that
portion of the outermost surface of the centralizer 838 that is
facing uphole and is traversed by a longitudinal axis of the
wellbore 102, and at least 50% (such as, for example, at least 60%,
such as, for example, at least 70%, such as, for example, at least
80%) of the total surface area of the solid particulate
accumulation-susceptible region 840 has a normal axis that is
disposed at an acute angle of less than 45 degrees (such as, for
example, less than 40 degrees, such as, for example, less than 35
degrees) relative to the longitudinal axis of the wellbore 102.
At a downhole end 844, the stinger 810 threadably connected to the
reservoir fluid conductor 202A such that fluid communication is
effected between stinger 810 and the reservoir fluid conductor
202A. In this respect, while the reservoir fluid conductor 202 is
receiving and conducting reservoir fluid that has entered the
wellbore 102 from the subterranean formation, the reservoir fluid
is conducted to the reservoir fluid receiver 623 of the flow
diverter body 602A via the stinger 810 and the overshot 808.
In some embodiments, for example, while the assembly 10 is being
deployed downhole, the stinger 810 is releasably secured relative
to the overshot 808 with one or more frangible members 842, such
as, for example, one or more shear pins.
In some embodiments, for example, the releasable securement of the
stinger 810 relative to the overshot 808 by the one or more
frangible members 842 is with effect that the one or more lugs 814
are disposed within a terminus of the j-slot 812 such that the
releasably connectible downhole production assembly 202 is
suspended by the one or more lugs 814 from the terminus. Referring
to FIG. 12, the locations 842A, at which the frangible members 842
effect the securement, are illustrated. Such configuration is
provided for minimizing stresses applied to the one or more
frangible members 842, thereby mitigating failure of the one or
more frangible members 842.
In other embodiments, for example, the releasable securement of the
stinger 810 relative to the overshot 808 by the one or more
frangible members 842 is with effect that the one or more lugs 814
are disposed within the j-slot 812, and supported by one or more
frangible members, such that the releasably connectible downhole
production assembly 202 is suspended from the one or more frangible
members 846, and the one or more lugs 814 are positioned within the
j-slot 812 such that, while the assembly 10 is being deployed
downhole, in response to receiving a force based upon impact of the
assembly 10 with a wellbore feature (such as, for example, a liner
top), there is an absence of interference to movement of the one or
more lugs 814, by the one or more frangible members, in an uphole
direction within the j-slot 812 (in this respect, in some of these
embodiments, the one or more lugs 814 are free to move uphole
within the j-slot 812). Referring to FIG. 12, the locations 846A,
at which the frangible members effect the securement, are
illustrated. This configuration is provided when it is intended to
deploy the assembly 10 within a wellbore 102 where there is a risk
that the assembly 10 will experience impact forces during
deployment, resulting in premature fracture of the one or more
frangible members 842 if the one or more frangible members 842 are
disposed otherwise in a position that renders them susceptible to
receive such impact forces.
In either case, once the assembly 10 is desirably positioned within
the wellbore 102, with the packers having been set, the overshot
808 is manipulated such that the one or more frangible members 842
are fractured for effecting release of the stinger 810 from
retention relative to the overshot 808, and after the release, the
overshot 808 is manipulated such that the one or more lugs become
desirable positioned within the j-slot 812 (when the one or more
lugs 814 are disposed in position 848 within the j-slot 812, the
releasably connectible downhole production assembly 202 is disposed
in tension, and when the one or more lugs 814 are disposed in
position 850, the releasably connectible downhole production
assembly 202 is disposed in compression).
The following outlines the steps of one operational embodiment for
connecting the releasably connectible uphole production assembly
601 to the releasably connectible downhole production assembly 202
that has already been positioned within the wellbore 102. In this
respect, the connecting involves connecting the overshot 808 to the
stinger 810. The releasably connectible uphole production assembly
601, including the overshot 808, is deployed downhole such that the
shroud assembly guides the stinger 810 into the overshot 808.
Further movement downhole of the overshot 808, relative to the
stinger 810, results in the lugs 814 entering the j-slot 812 such
that the lugs become disposed in position 850 within the j-slot 812
(see FIGS. 10 and 11). A left hand torque is then applied to the
releasably connectible uphole production assembly 601 from the
surface such that the lugs 814 will move within the j-slot 812 to
the position 848 within the j-slot 812 (see FIGS. 10 and 11),
resulting in the releasably connectible downhole production
assembly 202 being disposed in tension.
To effect disconnection of the overshot 808 from the stinger 810
and, therefore, the disconnection of the releasably connectible
uphole production assembly 601 from the releasably connectible
downhole production assembly 202, a left hand torque is applied to
the releasably connectible uphole production assembly 601, with
effect that the lugs 814 will leave the vertical section of the
j-slot 812. Continued application of the left hand torque, combined
with a pull in the uphole direction, ensures that the lugs 814
travel through the exiting path of the j-slot 812.
In the above description, for purposes of explanation, numerous
details are set forth in order to provide a thorough understanding
of the present disclosure. However, it will be apparent to one
skilled in the art that these specific details are not required in
order to practice the present disclosure. Although certain
dimensions and materials are described for implementing the
disclosed example embodiments, other suitable dimensions and/or
materials may be used within the scope of this disclosure. All such
modifications and variations, including all suitable current and
future changes in technology, are believed to be within the sphere
and scope of the present disclosure. All references mentioned are
hereby incorporated by reference in their entirety.
* * * * *